Calculate AS 2885.1 pipeline maximum allowable velocity for fluids subject to erosion.
The erosional velocity is calculated from the fluid density and the C Factor (API RP 14E). The fluid density can be calculated for single phase, two phase, or three phase fluids. DNVGL RP-O501 can be used for erosion rate calculations. Transmission pipelines which are transporting clean fluids are not normally subject to erosion.
Reference : Australian Standard AS 2885.1 : Pipelines - Gas And Liquid Petroleum Part 1 : Design And Construction (2015)
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CALCULATOR : AS 2885.1 Section 4.5.2 Steel Pipeline Maximum Fluid Velocity Three Phase Black Oil [PLUS] ±
Calculate the maximum recommended piping erosional velocity and flow rate for three phase oil water and gas or black oil (AS 2885.1 Section 4.5.2 : API 14E). For solids free fluids a maximum c value of 100 for continuous service, or 125 for intermittent service is recommended. For fluids treated with corrosion inhibitor, or for corrosion reistant materials a maximum c value of 150 to 200 may be used for continuous service, and upto 250 for intermittent service. For fluids with solids, the c value should be significantly reduced. Gas oil ratio (GOR) is the ratio of gas moles over oil volume. Gas moles are commonly measured as gas volume at standard conditions (eg SCF or SCM). Water cut is the volume ratio of water in liquid (oil and water). Reference : API 14E Recommended Practice For Design and Installation of Offshore Production Platform Piping Systems Tool Input- schdtype : Pipe Schedule Type
- diamtype : Pipe Diameter Type
- ODu : User Defined Outside Diameter
- IDu : User Defined Inside Diameter
- wtntype : Wall Thickness Type
- tnu : User Defined Wall Thickness
- mvtype : Fluid Density Type
- GORu : User Defined Gas Oil Ratio
- WCu : User Defined Water Cut
- ρu : User Defined Fluid Density
- cfactype : Erosional Velocity Factor Type
- Cu : User Defined Erosional Velocity Factor
- ρo : Oil Density
- ρw : Water Density
- P : Fluid Pressure
- T : Fluid Temperature
- Z : Gas Compressibility Factor
- SG : Gas Specific Gravity
Tool Output- ρf : Average Fluid Density
- ρg : Gas Density
- ρl : Liquid Density
- C : Erosional Velocity Factor
- GOR : Gas Oil Ratio
- ID : Inside Diameter
- Mf : Erosional Total Mass Flowrate
- Mg : Gas Mass Flowrate
- Ml : Liquid Mass Flowrate
- Mo : Oil Mass Flowrate
- Mw : Water Mass Flowrate
- Ng : Gas Mole Flowrate
- Qf : Erosional Total Volume Flowrate
- Qg : Gas Volume Flowrate
- Ql : Liquid Volume Flowrate
- Qo : Oil Volume Flowrate
- Qw : Water Volume Flowrate
- Vf : Erosional Total Fluid Velocity
- Vg : Gas Superficial Velocity
- Vl : Liquid Superficial Velocity
- Vo : Oil Superficial Velocity
- Vw : Water Superficial Velocity
- WC : Water Cut
- Xmg : Gas Mass Fraction
- Xml : Liquid Mass Fraction
- Xmo : Oil Mass Fraction
- Xmw : Water Mass Fraction
- Xvg : Gas Volume Fraction
- Xvl : Liquid Volume Fraction
- Xvo : Oil Volume Fraction
- Xvw : Water Volume Fraction
- vg : Gas Mole Volume (At T P)
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CALCULATOR : AS 2885.1 Section 4.5.2 Steel Pipeline Maximum Fluid Velocity Two Phase Gas Liquid [PLUS] ±
Calculate the maximum recommended piping erosional velocity and flow rate for two phase gas and oil (AS 2885.1 Section 4.5.2 : API 14E). For solids free fluids a maximum c value of 100 for continuous service, or 125 for intermittent service is recommended. For fluids treated with corrosion inhibitor, or for corrosion reistant materials a maximum c value of 150 to 200 may be used for continuous service, and upto 250 for intermittent service. For fluids with solids, the c value should be significantly reduced. Gas oil ratio (GOR) is the ratio of gas moles over oil volume. Gas moles are commonly measured as gas volume at standard conditions (eg SCF or SCM). Reference : API 14E Recommended Practice For Design and Installation of Offshore Production Platform Piping Systems Tool Input- schdtype : Pipe Schedule Type
- diamtype : Pipe Diameter Type
- ODu : User Defined Outside Diameter
- IDu : User Defined Inside Diameter
- wtntype : Wall Thickness Type
- tnu : User Defined Wall Thickness
- mvtype : Fluid Density Type
- GORu : User Defined Gas Oil Ratio
- Xmu : User Defined Gas Mass Fraction
- Xvu : User Defined Gas Volume Fraction
- ρu : User Defined Fluid Density
- cfactype : Erosional Velocity Factor Type
- Cu : User Defined Erosional Velocity Factor
- ρl : Liquid Density
- P : Fluid Pressure
- T : Fluid Temperature
- Z : Gas Compressibility Factor
- SG : Gas Specific Gravity
Tool Output- ρf : Average Fluid Density
- ρg : Gas Density (At T P)
- C : Erosional Velocity Factor
- GOR : Gas Oil Ratio
- ID : Inside Diameter
- Mf : Total Fluid Mass Flowrate
- Mg : Gas Mass Flowrate
- Ml : Liquid Mass Flowrate
- Ng : Gas Mole Flowrate
- Qf : Total Fluid Volume Flowrate
- Qg : Gas Volume Flowrate (At T P )
- Ql : Liquid Volume Flowrate
- Vf : Average Fluid Velocity
- Vg : Superficial Gas Velocity
- Vl : Superficial Liquid Velocity
- Xm : Gas Mass Fraction
- Xv : Gas Volume Fraction (At T P)
- vg : Gas Mole Volume (At T P)
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CALCULATOR : AS 2885.1 Section 4.5.2 Steel Pipeline Maximum Fluid Velocity Single Phase Gas [FREE] ±
Calculate the maximum recommended piping erosional velocity and flow rate for single phase gas (AS 2885.1 Section 4.5.2 : API 14E). For solids free fluids a maximum c value of 100 for continuous service, or 125 for intermittent service is recommended. For fluids treated with corrosion inhibitor, or for corrosion reistant materials a maximum c value of 150 to 200 may be used for continuous service, and upto 250 for intermittent service. For fluids with solids, the c value should be significantly reduced. Reference : API 14E Recommended Practice For Design and Installation of Offshore Production Platform Piping Systems Tool Input- schdtype : Pipe Schedule Type
- diamtype : Pipe Diameter Type
- ODu : User Defined Outside Diameter
- IDu : User Defined Inside Diameter
- wtntype : Wall Thickness Type
- tnu : User Defined Wall Thickness
- sgtype : Gas Specific Gravity Type
- SGu : User Defined Gas Specific Gravity
- Mu : User Defined Gas Molar Mass
- ρu : User Defined Gas Density
- cfactype : Erosional Velocity Factor Type
- Cu : User Defined Erosional Velocity Factor
- P : Gas Pressure
- T : Gas Temperature
- Z : Gas Compressibility Factor
Tool Output- ρ : Gas Density
- C : Erosional Velocity Factor
- ID : Inside Diameter
- M : Gas Molar Mass
- Mf : Gas Mass Flowrate
- Ng : Gas Mole Flowrate
- Qf : Gas Volume Flowrate (At T P)
- SG : Gas Specific Gravity
- Vf : Gas Velocity
- vg : Gas Mole Volume (At T P)
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CALCULATOR : AS 2885.1 Section 4.5.2 Steel Pipeline Maximum Fluid Velocity Single Phase Liquid [FREE] ±
Calculate the maximum recommended piping erosional velocity and flow rate for single phase liquid (AS 2885.1 Section 4.5.2 : API 14E). For solids free fluids a maximum c value of 100 for continuous service, or 125 for intermittent service is recommended. For fluids treated with corrosion inhibitor, or for corrosion reistant materials a maximum c value of 150 to 200 may be used for continuous service, and upto 250 for intermittent service. For fluids with solids, the c value should be significantly reduced. Reference : API 14E Recommended Practice For Design and Installation of Offshore Production Platform Piping Systems Tool Input- schdtype : Pipe Schedule Type
- diamtype : Pipe Diameter Type
- ODu : User Defined Outside Diameter
- IDu : User Defined Inside Diameter
- wtntype : Wall Thickness Type
- tnu : User Defined Wall Thickness
- sgtype : Density Type
- SGu : User Defined Specific Gravity
- Be+u : User Defined Degrees Baume SG > 1
- Be-u : User Defined Degrees Baume SG <= 1
- Twu : User Defined Degrees Twaddell SG > 1
- APIu : User Defined Degrees API SG <= 1
- ρu : User Defined Liquid Density
- cfactype : Erosional Velocity Factor Type
- Cu : User Defined Erosional Velocity Factor
Tool Output- ρ : Fluid Density
- API : Degrees API SG ≤ 1
- Be+ : Degrees Baume SG > 1
- Be- : Degrees Baume SG ≤ 1
- C : Erosional Velocity Factor
- ID : Inside Diameter
- Mf : Liquid Mass Flowrate
- Qf : Liquid Volume Flowrate
- SG : Specific Gravity
- Tw : Degrees Twaddell SG > 1
- Vf : Fluid Velocity
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CALCULATOR : AS 2885.1 Section 4.5.2 Steel Pipeline Maximum Fluid Velocity General [FREE] ±
Calculate the maximum recommended piping erosional velocity and flow rate from fluid density for general fluids (AS 2885.1 Section 4.5.2 : API 14E). For solids free fluids a maximum c value of 100 for continuous service, or 125 for intermittent service is recommended. For fluids treated with corrosion inhibitor, or for corrosion reistant materials a maximum c value of 150 to 200 may be used for continuous service, and upto 250 for intermittent service. For fluids with solids, the c value should be significantly reduced. Reference : API 14E Recommended Practice For Design and Installation of Offshore Production Platform Piping Systems Tool Input- schdtype : Pipe Schedule Type
- diamtype : Pipe Diameter Type
- ODu : User Defined Outside Diameter
- IDu : User Defined Inside Diameter
- wtntype : Wall Thickness Type
- tnu : User Defined Wall Thickness
- cfactype : Erosional Velocity Factor Type
- Cu : User Defined Erosional Velocity Factor
- ρ : Fluid Density
Tool Output- C : Erosional Velocity Factor
- ID : Inside Diameter
- Mf : Fluid Mass Flowrate
- Qf : Fluid Volume Flowrate
- Vf : Fluid Velocity
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CALCULATOR : AS 2885.1 Two Phase Gas Liquid Density [FREE] ±
Calculate AS 2885.1 pipeline fluid density for two phase gas liquid. Fluid density can be calculated for single phase fluid, single phase gas, and two phase gas liquid. Gas oil ratio (GOR) is the ratio of gas moles over oil volume. Gas moles are commonly measured as gas volume at standard conditions (eg SCF or SCM). Tool Input- mvtype : Fluid Density Type
- GORu : User Defined Gas Oil Ratio
- Xmu : User Defined Gas Mass Fraction
- Xvu : User Defined Gas Volume Fraction
- ρu : User Defined Fluid Density
- ρl : Liquid Density
- P : Fluid Pressure
- T : Fluid Temperature
- Z : Gas Compressibility Factor
- SG : Gas Specific Gravity
Tool Output- ρf : Average Fluid Density
- ρg : Gas Density (At T P)
- GOR : Gas Oil Ratio
- Xm : Gas Mass Fraction
- Xv : Gas Volume Fraction (At T P)
- vg : Gas Mole Volume (At T P)
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CALCULATOR : AS 2885.1 Three Phase Black Oil Density [FREE] ±
Calculate AS 2885.1 pipeline fluid density for three phase gas, oil and water (black oil). Black oil is a three phase mixture of oil, water and gas. Fluid density can be calculated for single phase oil, single phase water, single phase gas, two phase oil and water, or three phase gas, oil and water. Water cut is measured relative to the total liquid volume (gas volume is ignored). Gas oil ratio (GOR) is measured relative to the oil volume at standard conditions (water volume is ignored). Tool Input- mvtype : Fluid Density Type
- GORu : User Defined Gas Oil Ratio
- WCu : User Defined Water Cut
- ρu : User Defined Fluid Density
- ρo : Oil Density
- ρw : Water Density
- P : Fluid Pressure
- T : Fluid Temperature
- Z : Gas Compressibility Factor
- SG : Gas Specific Gravity
Tool Output- ρf : Average Fluid Density
- ρg : Gas Density
- ρl : Liquid Density
- GOR : Gas Oil Ratio
- WC : Water Cut
- Xmg : Gas Mass Fraction
- Xml : Liquid Mass Fraction
- Xmo : Oil Mass Fraction
- Xmw : Water Mass Fraction
- Xvg : Gas Volume Fraction
- Xvl : Liquid Volume Fraction
- Xvo : Oil Volume Fraction
- Xvw : Water Volume Fraction
- vg : Gas Mole Volume (At T P)
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CALCULATOR : AS 2885.1 Single Phase Gas Density [FREE] ±
Calculate AS 2885.1 pipeline fluid density for single phase gas. Gas molar mass is approximately equal to the molar mass of dry air times the gas specific gravity at standard conditions (for most gases the compressibility factor Z is approximately equal to 1 at standard conditions). The molar mass of dry air is taken as 28.964 kg/kg-mole. For gas mixtures, gas specific gravity is easier to measure than the molar mass. Tool Input- fluidtype : Gas Type
- SGu : User Defined Gas Specific Gravity
- Z : Gas Compressibility Factor
- P : Gas Pressure
- T : Gas Temperature
Tool Output- ρ : Gas Density
- M : Gas Molar Mass
- R : Gas Constant
- SG : Gas Specific Gravity
- vg : Gas Molar Volume (At T P)
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CALCULATOR : AS 2885.1 Single Phase Liquid Density [FREE] ±
Calculate AS 2885.1 pipeline fluid density for single phase liquid. For liquids lighter than or equal to water the density can be defined as degrees API, or degrees Baume (Be-). For liquids heavier than water the density can be defined by degrees Baume (Be+), or degrees Twaddell. Tool Input- sgtype : Density Type
- SGu : User Defined Specific Gravity
- Be+u : User Defined Degrees Baume SG > 1
- Be-u : User Defined Degrees Baume SG <= 1
- Twu : User Defined Degrees Twaddell SG > 1
- APIu : User Defined Degrees API SG <= 1
- ρu : User Defined Liquid Density
Tool Output- ρ : Fluid Density
- API : Degrees API SG ≤ 1
- Be+ : Degrees Baume SG > 1
- Be- : Degrees Baume SG ≤ 1
- SG : Specific Gravity
- Tw : Degrees Twaddell SG > 1
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